On the Imbibition Model for Oil-Water Replacement of Tight Sandstone Oil Reservoirs | Zendy

Xiong Liu | Zendy; Desheng Zhou | Zendy; Le Yan | Zendy; Shun Liu | Zendy; Yafei Liu | Zendy

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On the Imbibition Model for Oil-Water Replacement of Tight Sandstone Oil Reservoirs

Author(s) -

Xiong Liu,

Desheng Zhou,

Le Yan,

Shun Liu,

Yafei Liu

Publication year - 2021

Publication title -

geofluids

Language(s) - English

Resource type - Journals

SCImago Journal Rank - 0.44

H-Index - 56

eISSN - 1468-8123

pISSN - 1468-8115

DOI - 10.1155/2021/8846132

Subject(s) - imbibition , capillary pressure , relative permeability , petroleum engineering , pressure gradient , permeability (electromagnetism) , infiltration (hvac) , geology , capillary action , geotechnical engineering , materials science , porous medium , chemistry , porosity , composite material , biochemistry , oceanography , botany , germination , membrane , biology

A model suitable for evaluating a tight sandstone reservoir is established. The model includes two oil-water replacement modes: capillary force mode and osmotic pressure mode. The relationship between oil-water displacement rate and dimensionless time under different parameters is drawn considering the influence of capillary force, osmotic pressure, production pressure difference, and starting pressure gradient. Results indicate that the higher the relative permeability of the water phase, the lower the relative permeability of the oil phase, the smaller the oil-water viscosity ratio, and the higher the oil-water replacement rate. The relative permeability of the water phase also affects the infiltration stabilization time. Low salinity fracturing fluid infiltration helps to improve the oil-water replacement rate.

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